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Qin K.-Z.,CAS Institute of Geology and Geophysics | Tang D.-M.,CAS Institute of Geology and Geophysics | Su B.-X.,CAS Institute of Geology and Geophysics | Mao Y.-J.,CAS Institute of Geology and Geophysics | And 9 more authors.
Northwestern Geology | Year: 2012

The Northern Xinjiang is characterized by a large number of Permian mafic-ultramafic complexes with magmatic Cu-Ni sulfide mineralization in different tectonic unit. The identification of the top and bottom of these Cu-Ni sulfide-bearing mafic-ultamafic intrusions, a worldwide problem, is significant for the blind ore exploration. According to the outcrop area and lithofacies, these complexes can be divided into large complex 018-40 km2), small complex massif (1-5 km2) and simple rock-body (< 0. 1 km 2). The three types differ in body size, occurrence, lithofacies, the ratio of mafic and ultramafic bodies, ore-bearing lithology, space distribution of orebody and the ratio of Cu/Ni in orebody. The above-mentioned essential features of the complexes and mineral grain, alteration degree, basalt and diabase coeval with mafic-ultramafic intrusions, can determine the relative erosion degree of the deposits synthetically. The relative erosion degree in combination with the regional element geochemical and geophysics anomalies, are the effective measures to evaluate the Cu-Ni mineralization potential in mafic-ultramafic complexes. Mafic dykes, small intrusion, ultramafic outcrop in large mafic-ultramafic complex, strongly altered mafic-ultramafic intrusive rocks, gravity and magnetic anomaly zone superimposed geochemical anomalies, are the important target for finding small intrusion with large scale magmatic Cu-Ni sulfide deposits.

Zuo Y.,Chengdu University of Technology | Zuo Y.,China University of Petroleum - Beijing | Qiu N.,China University of Petroleum - Beijing | Li J.,CAS Institute of Geology and Geophysics | And 4 more authors.
Journal of Earth Science | Year: 2015

The thermal history of sedimentary basins is a key factor for hydrocarbon accumulation and resource assessment, and is critical in the exploration of lithospheric tectono-thermal evolution. In this paper, the Cenozoic thermal histories of nearly 200 wells and the Mesozoic thermal histories of 15 wells are modeled based on the vitrinite reflectance and apatite fission track data in Bohai Bay Basin, North China. The results show that the basin experienced Early Cretaceous and Paleogene heat flow peaks, which reveals two strong rift tectonic movements that occurred in the Cretaceous and the Paleogene in the basin, respectively. The thermal evolution history in Bohai Bay Basin can be divided into five stages including (1) the low and stable heat flow stage from the Triassic to the Jurassic, with the heat flow of 53 to 58 mW/m2; (2) the first heat flow peak from the Early Cretaceous to the middle of the Late Cretaceous, with a maximum heat flow of 81 to 87 mW/m2; (3) the first post-rift thermal subsidence stage from the middle of the Late Cretaceous to the Paleocene, with the heat flow of 65 to 74 mW/m2 at the end of the Cretaceous; (4) the second heat flow peak from the Eocene to the Oligocene, with a maximum heat flow of 81 to 88 mW/m2; and (5) the second thermal subsidence stage from the Neogene to present, with an average heat flow of 64 mW/m2. © 2015, China University of Geosciences and Springer-Verlag Berlin Heidelberg.

Zuo Y.,Chengdu University of Technology | Wang C.,Chengdu University of Technology | Tang S.,Chengdu University of Technology | Hao Q.,Institute of Mineral Resource Research
Journal of Petroleum Science and Engineering | Year: 2016

The hydrocarbon-bearing Baiyinchagan sag is located in the west of the Erlian Basin in the Inner Mongolia, Northern China. Its potential source rocks include the Lower Cretaceous Aershan, Tenggeer and Duhongmu 1 Formations. The former two formations are major source rocks. They are dominated by dark mudstone with the largest thickness of 560-600 m, and mainly distributed in the western sub-sag. In this study, temperature data from three wells used to calculate the present-day geothermal gradient in the sag, and used 144 vitrinite reflectance measurements from 35 wells together with seven apatite fission track data from seven wells to reconstruct the Mesozoic and Cenozoic thermal history. The results show that the present-day geothermal gradient is 35.1 °C/km. In the Early Cretaceous, the geothermal gradient was 40.0-42.1 °C/km during the early deposition of the Aershan Formation (135-110 Ma), and then increased to 49.9-56.4 °C/km at the end deposition of the Saihantala Formation (100-95 Ma). The geothermal gradient decreased to a present-day value of 32.0-35.4 °C/km. Using this model of thermal history, combined with the source rock geochemistry, the maturation histories of three source rock intervals, including the Aershan, Tenggeer and Duhongmu 1 Formations, were modeled. The modeled results suggest that source rock maturation was controlled by palaeo geothermal gradient, and that source rocks in the eastern sub-sag have not reached hydrocarbon generation threshold (0.5% Ro). In the western sub-sag, Aershan Formation source rocks reached a high mature (1.0%

Zuo Y.,China University of Petroleum - Beijing | Zuo Y.,Sinopec | Qiu N.,China University of Petroleum - Beijing | Pang X.,China University of Petroleum - Beijing | And 3 more authors.
Journal of Earth Science | Year: 2013

The Liaohe (Chinese Source) depression is an important part of the Bohai (Chinese Source) Bay Basin, and the Bohai Bay Basin located in the center of lithospheric destruction and thinning in the eastern North China Craton. The North China lithospheric thinning activities have been verified from evidences of structural geology, petrology, geochemistry and geophysics, but there are still some controversies on their timing, mechanism and controlling factors. The sedimentary basin is a thin-bedded geologic unit with a limited distribution in the upper lithosphere, and its formation and evolution represent the shallow response of the deep geodynamic process. Therefore, its thermal evolution is closely related to the deep dynamic conditions. In this article, the Mesozoic-Cenozoic thermal history of the Liaohe depression is reconstructed using the vitrinite reflectance and apatite fission track data. Meanwhile "thermal" lithospheric thicknesses in the Mesozoic and Cenozoic are calculated using the geothermic method on the basis of the above thermal history results. The results show that the Liaohe depression has under- peaks, 81 and 83 mW/m2, respectively, corresponding to two strong rift movements. Accordingly, the depression has experienced two different levels of thinning processes in the Cretaceous and the Paleogene since the Mesozoic, and the "thermal" lithospheric thicknesses were 60 and 50 km, respectively. This may reveal that the depression has experienced two large-scale destructions. The work may provide valuable geothermal evidence for initial revealing the time, process and stage of the lithospheric thinning in the Liaohe depression. © 2013 China University of Geosciences and Springer-Verlag Berlin Heidelberg.

Li J.M.,China University of Petroleum - Beijing | Tang L.J.,China University of Petroleum - Beijing | Yue Y.,Sinopec | Li M.,Institute of Mineral Resource Research | And 3 more authors.
Arabian Journal of Geosciences | Year: 2016

A three-dimensional (3D) structural modeling of the Lower Cambrian–Upper Permian Yubei 3D area was performed to understand its structural evolution. This model reproduces the present-day structure of the basin and comprises 11 horizons within Lower Cambrian to Upper Permian rocks. The analysis is based on 3D depth views and faults. The results image salt movements due to tectonics and/or burial. From these observations, this paper deduces that salt structures are correlated to the main faults and tectonic events. From the model analysis, we interpret the timing and geometry of Tarim Basin tectonics. The fault geometry can be resolved based on the strike of the fault, the morphology of hanging wall strata, and the stratigraphic distribution. Emphasis is placed on gypsum rock detachment, considering its movements during the Middle Caledonian event and decoupling effects during tectonic evolution. Moreover, we point to the structural control of the Paleozoic basement and the crustal architecture (Yubei 3D Zone) on the geometry of the Tarim Basin. © 2016, Saudi Society for Geosciences.

Zhen S.-J.,China University of Petroleum - Beijing | Tang L.-J.,China University of Petroleum - Beijing | Li Z.-J.,Sinopec | Li M.,China University of Petroleum - Beijing | And 3 more authors.
Natural Gas Geoscience | Year: 2015

The Ordovician reservoir of the Shunnan area showed a good oil and gas exploration potential. Based on the 3D seismic interpretation and attribute extraction technique, the structural characteristics, formation mechanism and petroleum geology significance were discussed in the profile as well as the section, providing a new idea for the geological structure modeling and oil and gas exploration. Studies show that there are three different trending strike-slip faults. The NE- and NEE-striking faults show sinistral strike-slip, while the smaller-scale, NW-striking faults were characterized by dextral strike slip. The NE-striking fault formed a typical flower structure, while the NEE and NW are relatively simple, manifested as single and vertical fault. In the III screen of middle Caledonian, Tazhong No. 1 Structural Zone thrust fault was formed by a nearly N-S-striking compression. In its tectonic deformation divisions, there occurred strike-slip component perpendicular to Tazhong No. 1 Structural Zone, and developed NE- and NEE-trending strike-slip faults in Shunnan area. The blocks restricted by the two sets of sinistral strike-slip faults have a counterclockwise trend, resulting in NW-striking dextral shear deformation in the internal blocks. The controlling of strike-slip faults on hydrothermal karst mainly manifested in linear karstification along the NE- and NEE-trending strike-slip fault, and planar karstification involved in the NW strike-slip faults. The strike-slip fault is also taken as the path of vertical oil and gas migration. © 2015, Science Press. All right reserved.

Zuo Y.-H.,Chengdu University of Technology | Zuo Y.-H.,China University of Petroleum - Beijing | Zuo Y.-H.,Sinopec | Qiu N.-S.,China University of Petroleum - Beijing | And 7 more authors.
Marine and Petroleum Geology | Year: 2014

The Chagan sag has the greatest oil and gas exploration potential among other sags in the Yingen Ejinaqi Basin, Inner Mongolia. The average geothermal gradient in the Chagan sag is 33.6 °C/km, whereas the heat flow ranges from 65.9 mW/m2 to approximately 85.5 mW/m2, with an average value of 74.5 mW/m2. Thermal history reveals that the Chagan sag experienced the following 4 stages of thermal evolutions: (1) a rapidly increasing geothermal gradient stage from the Early Cretaceous Bayingebi Formation depositional period to the Early Cretaceous Suhongtu Formation depositional period; (2) a geothermal gradient peak stage during the Early Cretaceous Yingen Formation depositional period; (3) a high geothermal gradient continuation stage during the Late Cretaceous Wulansuhai Formation depositional period; and (4) a thermal subsidence stage during the Cenozoic. Tectonic subsidence analysis reveals that the area experienced an initial synrift subsidence during the Early Cretaceous followed by a subsequent long-term thermal subsidence since Late Cretaceous. Thermal and tectonic subsidence histories of this area are of great significance to petroleum exploration and hydrocarbon resource assessment because they bear directly on issues of source rock maturation. The maturation histories of the 3 sets of source rocks in the sag were modeled on the basis of the present geothermal field, thermal history and tectonic subsidence history. The results reveal that the hydrocarbon generation of the Chagan sag was controlled by the Early Cretaceous geothermal fields, and the source rock maturity reached the maximum at the end of the Yingen Formation depositional period. Moreover, the maturation evolution degree shows a difference for the 3 sets of source rocks. The source rocks of the Bayingebi 1 and 2 Formations reached the middle mature and dry-gas stage. In contrast, the source rocks of the Suhongtu 1 Formation only reached the early mature and middle mature stage. This work may provide new insights for the understanding of the oil and gas exploration potential of the Chagan sag. © 2014 Elsevier Ltd.

Zuo Y.,Chengdu University of Technology | Zuo Y.,Petrochina | Zuo Y.,China University of Petroleum - Beijing | Qiu N.,China University of Petroleum - Beijing | And 6 more authors.
Acta Geologica Sinica | Year: 2014

The Dongpu sag is located in the south of the Bohai Bay basin, China, and has abundant oil and gas reserves. To date, there has been no systematic documentation of its geothermal fields. This study measured the rock thermal conductivity of 324 cores from 47 wells, and calculated rock thermal conductivity for different formations. The geothermal gradient and terrestrial heat flow were calculated for 192 wells on basis of 892 formation-testing data from 523 wells. The results show that the Dongpu sag is characterized by a medium-temperature geothermal field between stable and active tectonic areas, with an average geothermal gradient of 32.0°C/km and terrestrial heat how of 65.6 mW/m2. The geothermal fields in the Dongpu sag is significantly controlled by the Changyuan, Yellow River, and Lanliao basement faults. They developed in the Paleogene and the Dongying movement occurred at the Dongying Formation depositional period. The geothermal fields distribution has a similar characteristic to the tectonic framework of the I)ongpu sag, namely two subsags, one uplift, one steep slope and one gentle slope. The oil and gas distribution is closely associated with the present geothermal fields. The work may provide constraints for reconstructing the thermal history and modeling source rock maturation evolution in the Dongpu sag. © 2014 Geological Society of China.

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